CN115746808B - Plugging agent and application thereof - Google Patents
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- CN115746808B CN115746808B CN202111037199.1A CN202111037199A CN115746808B CN 115746808 B CN115746808 B CN 115746808B CN 202111037199 A CN202111037199 A CN 202111037199A CN 115746808 B CN115746808 B CN 115746808B
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- 239000003795 chemical substances by application Substances 0.000 claims abstract description 70
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 56
- 238000006073 displacement reaction Methods 0.000 claims abstract description 22
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 17
- 239000010426 asphalt Substances 0.000 claims abstract description 16
- 238000010276 construction Methods 0.000 claims abstract description 16
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 claims abstract description 13
- 229910052804 chromium Inorganic materials 0.000 claims abstract description 13
- 239000011651 chromium Substances 0.000 claims abstract description 13
- 239000005011 phenolic resin Substances 0.000 claims abstract description 12
- 229920001568 phenolic resin Polymers 0.000 claims abstract description 11
- -1 sulfomethyl phenolic resin Chemical compound 0.000 claims abstract description 11
- 239000003921 oil Substances 0.000 claims description 70
- 238000002347 injection Methods 0.000 claims description 43
- 239000007924 injection Substances 0.000 claims description 43
- 239000010779 crude oil Substances 0.000 claims description 12
- 230000035699 permeability Effects 0.000 claims description 11
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims description 10
- 229920002401 polyacrylamide Polymers 0.000 claims description 9
- 235000020681 well water Nutrition 0.000 claims description 6
- 239000002349 well water Substances 0.000 claims description 6
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 4
- 239000000295 fuel oil Substances 0.000 claims description 3
- 235000013311 vegetables Nutrition 0.000 claims description 2
- 229920000642 polymer Polymers 0.000 abstract description 16
- 239000007800 oxidant agent Substances 0.000 abstract description 11
- 238000011084 recovery Methods 0.000 abstract description 10
- 230000001590 oxidative effect Effects 0.000 abstract description 6
- 238000012360 testing method Methods 0.000 description 14
- 230000000694 effects Effects 0.000 description 13
- 238000005516 engineering process Methods 0.000 description 13
- 238000000034 method Methods 0.000 description 10
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- 230000000052 comparative effect Effects 0.000 description 4
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- 238000003756 stirring Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- 238000010521 absorption reaction Methods 0.000 description 2
- 239000004568 cement Substances 0.000 description 2
- 229910001430 chromium ion Inorganic materials 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- 239000002994 raw material Substances 0.000 description 2
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- 238000013112 stability test Methods 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
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- 239000011159 matrix material Substances 0.000 description 1
- 230000005486 microgravity Effects 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
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Abstract
The invention provides a plugging agent and application thereof. Based on 100% of the total weight of the plugging agent, the plugging agent comprises 0.01% -0.02% of oxidant, 0.14% -0.2% of polymer, 0.12% -0.16% of organic chromium cross-linking agent, 1% -3% of asphalt, 0.8% -1.2% of sulfomethyl phenolic resin and the balance of water. The invention also provides application of the plugging agent in oil displacement construction. The plugging agent provided by the invention can form weak gel in stratum, has certain heat resistance and supporting strength, and can obviously improve the recovery ratio of oil field when being applied to oil displacement construction.
Description
Technical Field
The invention relates to the technical field of petrochemical products, in particular to a plugging agent and application thereof.
Background
The overall water drive recovery rate of land oil fields in China is low and is generally lower than 50%, and one of the important reasons is that the sweep efficiency of water drive is low. One important factor affecting water drive sweep efficiency is reservoir heterogeneity. For the oil field developed by water injection, due to the complexity of a pore structure and the surface property of rock, oil reservoirs are heterogeneous, so that water cannot advance uniformly in a piston manner, injected water is caused to protrude along a hypertonic layer section, and a local water channeling phenomenon occurs, thereby greatly reducing the sweep efficiency of the injected water and restricting the improvement of recovery ratio. The basic idea of various measures adopted for the heterogeneity of the oil reservoir is to effectively block the high permeable layer, change the flow direction of the subsequent injection fluid, and improve the swept volume of the displacement agent, thereby improving the oil displacement efficiency. The profile control and water shutoff technology is generated.
The weak gel profile control technology is a novel tertiary oil recovery technology which is generated on the basis of profile control and water shutoff of an oil reservoir and polymer flooding and combines the advantages of deep profile control of the oil reservoir and polymer flooding to improve sweep efficiency. The main effects which can be achieved by the method are as follows: the thickness of the oil producing layer is increased, the thickness of the high water bearing layer is reduced, and the liquid producing section of the oil well is improved; the water absorption section of the water injection well is improved, the water absorption capacity of the low-permeability layer is improved, the sweep efficiency of injected water is improved, and the water driving effect is improved; the oil yield is improved, and the oil production cost and the treatment cost of crude oil and sewage on the ground are reduced; the water injection development effect is improved on the whole, the water content rising speed of the block is reduced, the yield decreasing speed is reduced, and the slope of the water drive characteristic curve of the block is reduced.
The water-based cement paste is used as the selective plugging agent, and is developed into crude oil, viscous oil, hydrophobic oil-water emulsion, solid hydrocarbon solution, oil-based cement and the like. Needleham et al in 1974 indicated that the adsorption and mechanical trapping effects of polyacrylamide in porous media could be used to effectively block high-water-content layers, thus bringing the development of chemical water shutoff and profile control technology into a new stage. The chemical water shutoff technology of the oil field is well applied and developed from the last 70 s to the first 80 s, and then the technology is developed into a water injection well profile control technology and a deep profile control technology.
Another important factor affecting the sweep efficiency of injected water is the mobility ratio of the oil to water. In the process of water displacement of crude oil, the unfavorable oil-water fluidity ratio is easy to cause viscous fingering of injected water, so that the water drive sweep volume and the oil drive efficiency are reduced. In order to adjust the viscosity difference between the displacement fluid and the oil, improve the fluidity ratio and the swept volume of the displacement fluid, a polymer oil displacement technology is developed. The tertiary oil recovery technology is developed rapidly at home and abroad and is widely paid attention to various oil fields. In particular, after potential analysis of enhanced recovery of water-flooding oil fields in China, the enhanced sweep efficiency of polymer flooding is determined to be used as the main attack direction of recent tertiary oil recovery in China. At present, the polymer flooding has formed a relatively perfect matched process technology, the mine pilot test has generally been successful, and the industrial tests of oil fields such as Daqing, victory and the like have also obtained obvious effects.
Disclosure of Invention
In order to solve the above problems, the present invention provides a plugging agent and its application. The plugging agent can form weak gel in stratum, has certain heat resistance and supporting strength, and can obviously improve the recovery ratio of oil field when being applied to oil displacement construction.
In order to achieve the aim, the invention provides a plugging agent, which comprises, by weight, 100% of the total plugging agent, 0.01% -0.02% of an oxidizing agent, 0.14% -0.2% of a polymer, 0.12% -0.16% of an organic chromium cross-linking agent, 1% -3% of asphalt, 1% of sulfomethyl phenolic resin and the balance of water.
The plugging agent provided by the invention forms weak gel in a stratum, the weak gel is sheared by the stratum in the migration process, gel groups with smaller volumes are formed by breaking the weak gel, and the gel groups are redistributed and aggregated in the process of migrating to the deep part of the stratum, so that the microstress distribution in a porous medium is changed, and the residual oil in the stratum can be displaced under the viscous force of a post-injection displacement fluid. The plugging agent can form a plugging wait with a certain thickness near a near well zone, realizes shielding temporary plugging, and has the characteristics of high temperature resistance and high plugging rate.
In the plugging agent, the oxidant has a certain plugging removal effect, and gel formed by the plugging agent can be pushed to migrate to the stratum deep layer. The oxidizing agent may include thiourea and the like.
In the above plugging agent, the polymer includes polyacrylamide and/or phenol resin, etc., for example, polyacrylamide having a weight average molecular weight of 1200X 10 4-2000×104 g/mol.
In the plugging agent, the organic chromium crosslinking agent is used for crosslinking the polymer to form weak gel. The chromium ions in the organochromium crosslinking agent may be chromium salts, complex chromium, chromium ions, etc., for example, the organochromium crosslinking agent may include:
Wherein m=5-12, n=3-6.
In the plugging agent, the asphalt and the sulfomethyl phenolic resin can synergistically improve the propping property and strength of a weak gel system formed by the plugging agent. The bitumen also can improve the heat resistance of the weak gel system, enabling the weak gel system to have a certain stability under formation temperature conditions. In some embodiments, the asphalt comprises vegetable asphalt, and the like.
In a specific embodiment of the present invention, the plugging agent may comprise 0.01% of an oxidizing agent, 0.18% of a polymer, 0.14% to 0.15% of an organochromium crosslinking agent, 1.2% to 2% of asphalt, 1% of sulfomethyl phenolic resin, and the balance water, based on 100% by weight of the total plugging agent.
In a specific embodiment of the present invention, the plugging agent forms a gel (typically a weak gel) after injection into the formation, the gel having an initial viscosity of typically 200 mPas to 500 mPas.
In a specific embodiment of the present invention, the preparation method of the plugging agent may include: adding the polymer and the organic chromium crosslinking agent into water, stirring, then adding the oxidant, asphalt and sulfomethyl phenolic resin, and stirring uniformly to obtain the plugging agent.
The invention further provides application of the plugging agent in oil displacement construction, for example, in oil displacement construction of oil fields (common heavy oil reservoirs, thin oil reservoirs and the like) with large stratum oil-water flow ratio and uneven reservoir utilization. The plugging agent can form a weak gel system after being injected into a stratum, and the contradiction between the vertical and plane of an oil layer can be solved by using a weak gel oil displacement technology. Specifically, after the high permeability channel is formed, water is generally injected after the plugging agent is injected to form weak gel for a period of time, on one hand, the subsequent injection water forces the weak gel to migrate to the deep part of the stratum, and on the other hand, the injection water further waves to surrounding medium-low permeability layers, so that the vertical and plane wave and degree of the injection water are improved to the greatest extent. In the process of the weak gel moving to the deep part of the stratum, the oil displacement effect is also provided, so that the residual oil in the passing area is driven out. Compared with the conventional oil displacement technology, the weak gel formed by the plugging agent provided by the invention has more remarkable effect in the deep part of the stratum, and the effect of large-dose treatment can be achieved by adopting a smaller quantity of weak gel to migrate in the stratum. In some embodiments, the plugging agent forms a plugging system with a plugging rate of up to 95% or more.
In a specific embodiment of the invention, the profile control radius of the profile control agent in the oil displacement construction process can be calculated according to the following formula:
Wherein R is a profile control radius and m; f g is the ratio of the injection capacity before and after the treatment of the profile control and flooding interval; r w is the wellbore radius, m; r e is the injection well water injection influence radius, m; RRF is the residual drag coefficient. In some embodiments, f g may be the ratio of the daily injection amounts before and after flooding with the same injection pressure, as measured by performing an in-house experiment in advance.
In a specific embodiment of the invention, the injection amount of the plugging agent in the oil displacement construction process can be calculated according to the following formula:
Wherein Q is injection quantity, square; k is the permeability, md (millidarcy); h is the thickness of the oil layer, m; μ is the viscosity of the crude oil, mpa.s (millipascal seconds); p w is the bottom hole pressure of the profile control well, p e is the average pressure of the oil layer, r w is the radius of the well shaft, and m; and r e is the injection well water injection influence radius, m.
The invention has the beneficial effects that:
The plugging agent provided by the invention can form weak gel in a stratum, has high temperature resistance and high strength in the stratum, can effectively penetrate deep into the stratum, changes microgravity distribution of porous media in the stratum, is matched with subsequent displacement fluid, and has displacement effect on residual oil in the stratum.
Drawings
FIG. 1 shows the results of the thermal stability test of test example 2.
Detailed Description
The technical solution of the present invention will be described in detail below for a clearer understanding of technical features, objects and advantageous effects of the present invention, but should not be construed as limiting the scope of the present invention.
Example 1
The embodiment provides a plugging agent, and the preparation method comprises the following steps:
1. Weighing the raw materials: based on 100 percent of the total weight of the raw materials, 0.01 percent of thiourea (used as an oxidant), 0.18 percent of polyacrylamide (used as a polymer), 0.15 percent of organic chromium crosslinking agent, 1.2 percent of asphalt, 1 percent of sulfomethyl phenolic resin and the balance of water are weighed.
Wherein the weight average molecular weight of the polyacrylamide is 1800 multiplied by 10 4 g/mol, and the organic chromium crosslinking agent is:
Wherein, m=5-12, n=3-6, the manufacturer of the organic chromium cross-linking agent is the sea wave chemical industry.
2. In a site configuration pool, adding the weighed polyacrylamide and the organic chromium crosslinking agent into water, uniformly stirring, then adding asphalt, sulfomethyl phenolic resin and thiourea, and uniformly stirring to obtain the plugging agent.
Test example 1
The test example provides the application effect of the plugging agent in oilfield construction. The oil field to be constructed belongs to a common heavy oil reservoir developed by water injection. The oil-containing area of the oil reservoir is 5.9km 2, the effective thickness of the average oil layer is 11.6m, and the geological reserve of crude oil is 1227 multiplied by 10 4 t. The average porosity is 29.1%, the average permeability is 633 multiplied by 10 -3μm2, the original stratum pressure is 17.5MPa, the saturation pressure is 16.4MPa, the reservoir burial depth is 1650m-2100m, and the oil-bearing well section is 200m-300m. The oil reservoir type belongs to a lamellar side water oil reservoir and a lithologic oil reservoir. The viscosity of the crude oil at formation conditions was 82.5 mPas. The oil reservoir has high utilization degree, and the geological reserve recovery degree of the oil reservoir is 35.49 percent before the plugging agent regulating measures are utilized, so that the oil reservoir enters a high-water-content development stage, and the residual oil is scattered.
The plugging agent prepared in the embodiment 1 is used for the construction of the oil reservoir, the injection amount of the plugging agent in the construction process is 180 ten thousand tons, the injection speed is 275m 3/d, the injection pressure is designed to be 9-12MPa, the rated working pressure is selected as the injection equipment, the discharge capacity is 3-10m 3, and the profile control pump with the frequency modulation motor is arranged. The transfer pump adopts a screw pump with the discharge capacity of 50m 3/h and the lift of 10 m.
The injection amount of the plugging agent is calculated according to the following formula:
Wherein Q is injection quantity, square; k is permeability, md; h is the thickness of the oil layer, m; mu is the viscosity of crude oil and mPa.s; p w is the bottom hole pressure of the profile control well, p e is the average pressure of the oil layer, r w is the radius of the well shaft, and m; and r e is the injection well water injection influence radius, m.
The profile control radius of the profile control agent in the oil displacement construction process is calculated according to the following formula:
Wherein R is a profile control radius and m; f g is the ratio of the injection capacity before and after the treatment of the profile control and flooding interval; r w is the wellbore radius, m; r e is the injection well water injection influence radius, m; RRF is the residual drag coefficient. In some embodiments, f g in the present test example is the ratio of the daily injection amounts before and after the profile control with the same injection pressure measured by performing an indoor experiment in advance.
And finally, calculating to obtain the profile control radius of the profile control agent which is 60-110m and the profile control well spacing of 1/3-2/3.
76.2 Ten thousand tons of accumulated oil and 9.9 ten thousand tons of accumulated oil are produced after construction, and the measure effect is obvious. The effective period of the measure reaches 4 years.
The plugging agent prepared in the example 1 is accumulated and implemented for 38 wells in a certain oil extraction factory, and the construction success rate is 88.9%.
The results show that the plugging agent provided by the invention can improve the plane and vertical sweep degree of injected water, effectively displace residual crude oil in an oil field, and improve the recovery ratio of the oil field with large stratum oil-water flow ratio and uneven reservoir utilization.
Comparative example 1
The comparative example provides a plugging agent, which comprises, based on 100% of the total weight of the plugging agent, 0.01% of an oxidant, 0.18% of a polymer, 0.14% of an organic chromium crosslinking agent, and the balance of water. The types of oxidizing agent, polymer and organochromium crosslinking agent used in this comparative example were the same as in example 1, and the plugging control agent was prepared in the same manner as in example 1.
Example 2
The embodiment provides a plugging agent, which comprises, based on 100% of the total weight of the plugging agent, 0.01% of an oxidant, 0.18% of a polymer, 0.14% of an organic chromium crosslinking agent, 2% of asphalt, 1% of sulfomethyl phenolic resin and the balance of water. The types of oxidizing agent, polymer and organochromium crosslinking agent used in this example were the same as in example 1, and the plugging control agent was prepared in the same manner as in example 1.
Test example 2
The thermal stability of the plugging agents prepared in example 2 and comparative example 1 was tested at 20-200 c by placing a sample of the plugging agent in an incubator and taking out the plugging agent at intervals to measure the temperature and viscosity of the plugging agent.
FIG. 1 shows the results of the thermal stability test described above. From fig. 1, it can be seen that the thermal stability of the plugging agent can be effectively improved by adding the sulfomethyl phenolic resin and the asphalt.
Test example 3
This test example tests the plugging performance of the plugging control agent of example 1.
The test uses a certain oil field to inject water, a certain oil reservoir crude oil (the viscosity of the crude oil is 4.13mPa.s at 100 ℃) and a fractured artificial sandstone columnar core. The experimental temperature was 100 ℃.
The testing method comprises the following steps: and (3) vacuumizing the rock core, saturating and simulating injection water, driving the rock core to be stable in pressure by using water with the flow rate of 1mI/min, testing the water phase permeability of the rock core, driving the oil to be bound water, driving the water to be in a residual oil state after 24 hours, injecting a 2PV gel profile control and driving agent, keeping the temperature at 100 ℃ for 72 hours, continuously driving by using the simulated injection water, and testing the water phase permeability after plugging. The blocking rate is the ratio of the difference between the water permeability before and after the porous medium is blocked and the water permeability before blocking, and the experimental results are shown in table 1.
Table 1 blocking Properties of the blocking System
As can be seen from Table 1, for the core with permeability of (119-306) x 10 -3μm2, the plugging rate of the profile control and flooding system provided by the invention is over 95%, which indicates that the system has certain capacity of plugging high-permeability large pore channels, but is blocked but not dead, has strong mobility and has potential of displacing crude oil in a matrix.
Claims (9)
1. The plugging agent comprises, by weight, 100% of the total plugging agent, 0.01% -0.02% of thiourea, 0.14% -0.2% of polyacrylamide, 0.12% -0.16% of organic chromium cross-linking agent, 1% -3% of asphalt, 0.8% -1.2% of sulfomethyl phenolic resin and the balance of water.
2. The plugging agent of claim 1, wherein the polyacrylamide has a weight average molecular weight of 1200 x 10 4-2000×104 g/mol.
3. The plugging agent of claim 1, wherein the asphalt comprises vegetable asphalt.
4. The plugging agent of claim 1, wherein the plugging agent comprises 0.01% thiourea, 0.18% polyacrylamide, 0.14% -0.15% organic chromium cross-linking agent, 1.2% -2% asphalt, 1% sulfomethyl phenolic resin, and the balance water, based on 100% total weight of the plugging agent.
5. The plugging agent of claim 1, wherein the plugging agent forms a gel after injection into a formation, the gel having an initial viscosity of 200 mPa-s to 500 mPa-s.
6. The use of the plugging agent according to any one of claims 1 to 5 in oil displacement construction.
7. The use of claim 6, wherein the reservoir in which the flooding construction is performed comprises a heavy oil reservoir and/or a thin oil reservoir.
8. The use of claim 6 or 7, wherein the profile control radius of the profile control agent during the displacement of reservoir oil is calculated according to the following formula:
Wherein R is a profile control radius and m; f g is the ratio of the injection capacity before and after the treatment of the profile control and flooding interval; r w is the wellbore radius, m; r e is the injection well water injection influence radius, m; RRF is the residual drag coefficient.
9. The use according to any one of claims 6-8, wherein the injection amount of the plugging agent during the flooding construction is calculated according to the following formula:
Wherein Q is injection quantity, square; k is permeability, md, h is thickness of oil layer, m; mu is the viscosity of crude oil and mPa.s; p w is the bottom pressure of the profile control well and MPa; p e is the average pressure of the oil layer and MPa; r w is the wellbore radius, m; and r e is the injection well water injection influence radius, m.
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